Conference Call 4º Quarter of 2012

Highlights  24.5% increase in Net Revenue (without construction revenue) reaching R$ 1,963.6 million in the 4Q12 and R$ 6,943.1 million in 2002, an increase of 12.9%.  R$ million EBITDA in 4Q12, 49.5% increase. In 2012, EBITDA reached R$ 1,456.2 million, 17.7% higher than in the  R$ million of net Income in 4Q12, an increase of 21.3%. In 2012, net income was up 24.0%, totaling R $ million.  On March 25, Board of Directors approved the proposal to distribute additional dividends of R$ 91,770,327.00, or R$ 0.45 per share, to be decided at the OGM in April.  Net debt of R$ 4,273.1 million, and multiple for covenants effect of 2.9x. RESULTS CAPITAL MARKETS  Consumption grew 5.2% compared to 4Q11, manly driven by the major temperature and by the commercial segment whch increased its consumption by 13.5%. In 2012 the consumption grew 2.0%. Adjusting by the clients with long-term default the consumption increase was 3,0%;  Collection rate (LTM) for the last 12 months reached 98.0%, 60 bps above the same period last year;  Non-technical losses reached 45.4% over the low-voltage market, due to the change in criteria of clients with long-term default;  In 2012, investments amounted R$796.8 million, been R$694.1 million for the distribuition segment only. OPERATIONAL

Energy Consumption Distribution – Quarter +5.2% 5,673 5, ºC 26.1ºC 4Q11 4Q10 5,716 5,965 4Q ºC 25.9ºC +1.5% 4Q12 1 Note: To preserve comparability in the market approved by Aneel in the tariff adjustment process, the billed energy of the free customers Valesul, CSN and CSA were excluded in view of these customers’ planned migration to the Basic Network. TOTAL MARKET (GWh) ¹ Industrial 7% Free 14% Others 15% Commercial 30% Residential 34% With the consumption no longer billed by the change in criteria, the total energy consumption increase in the concession area would be 6.3% over 2011.

+2.0% 22,932 22, ºC 24.3ºC ,492 23, ºC 25.0ºC +2.9% Note: To preserve comparability in the market approved by Aneel in the tariff adjustment process, the billed energy of the free customers Valesul, CSN and CSA were excluded in view of these customers’ planned migration to the Basic Network. TOTAL MARKET (GWh) ¹ Energy Consumption Distribution – Year Industrial 7% Free 14% Others 15% Commercial 29% Residential 35% With the consumption no longer billed by the change in criteria, the total energy consumption increase in the concession area would be 3.0% over 2011.

Total Market RESIDENTIALINDUSTRIALCOMMERCIAL OTHERS TOTAL 4Q114Q % 4,904 5,114 5, , % % 1,587 1,795 1, , , % 2,006 2,032 ELECTRICITY CONSUMPTION (GWh) TOTAL MARKET – QUARTER 4Q114Q12 4Q114Q12 4Q114Q12 4Q114Q % FREE CAPTIVE

Total Market FREE CAPTIVE RESIDENTIALINDUSTRIALCOMMERCIAL OTHERS TOTAL % ,932 3,056 3,330 23, % 3,417 3,521 3, , % 6,310 6,856 6, ,599 1,731 1,528 3,944 2,213 2,396 3, % 8,418 8,149 ELECTRICITY CONSUMPTION (GWh) TOTAL MARKET – YEAR %

Collection 102.5% COLLECTION RATE 12 MONTHS COLLECTION RATE BY SEGMENT YEAR 97.4% 98.0% 96.4% 94.3% 101.0% 98.8% 102.6% % 98.0% Dec/11Dec/12 TotalRetailLarge ClientsPublic Sector

Loss Prevention INCORPORATION GWh % ENERGY RECOVERY GWh LOSS (12 MONTHS) 41.2% 40.4% 33.3% % Non-technical losses/ LV Market Non-technical losses GWh Technical losses GWh % Non-technical losses / LV Market - Regulatory 5,316 2,349 7,582 7, % +12.5% Dec/12Mar/12Dec/11 2,335 5, % 5,615 2,432 8,047 Jun/12 Reflets the change on treatment's criteria in the approach to long term delinquent customers, based on Aneel Resolution ,457 2,381 7,838 Sep/ % 6,007 2,529 8,536

Net Revenue Industrial 6.8% NET REVENUE (R$MN) Generation 6.3% Distribution 89.6%** NET REVENUE BY SEGMENT (2012)* Commercialization 4.1% * Eliminations not considered ** Construction revenue not considered NET REVENUE FROM DISTRIBUTION (2012) Commercial 30.1% Others (Captive) 12.6% Network Use (TUSD) (Free + Concessionaires) 9.4% Residential 41.1% Construction Revenue Revenue w/out construction revenue , , Q124Q , , % , , , , % 12.9%

Operating Costs and Expenses Manageable (distribution): R$ (9.3%) Generation and Commercialization: R$ (8.2%) Non manageable (distribution): R$ 1,328.5 (82.6%) * Eliminations not considered ** Construction revenue not considered DISTRIBUTION MANAGEABLE COSTS (R$MN) COSTS (R$MN)* 4Q % 4Q12 4Q , , % R$ MN4Q114Q12Var Var. PMSO % % Provisions56, % % PCLD % % Contingencies % % Depreciation % % Other operational/ revenues expenses 1.0(357.5)-6.0(355.0)- Total %1,258.91, %

EBITDA CONSOLIDATED EBITDA (R$MN) EBITDA BY SEGMENT* 2012 Generation 23,0% (EBITDA Margin: 76,4%) Commercialization 1,9% (EBITDA Margin: 9,5%) Distribution 75,2% (EBITDA Margin: 17,4%) *Eliminations not considered % 4Q114Q , , %

EBITDA EBITDA 4Q11 EBITDA 4Q12 Net Revenue Non- Managable Costs Managable Costs (PMSO) Provisions 32 Regulatory Assets and Liabilities Adjusted EBITDA 4Q11 Adjusted EBITDA 4Q (356) (41) EBITDA – 4Q11 / 4Q12 (R$ MN) % % Other operational/ revenues (194)

EBITDA 87 1,325 1, (706) (75) 381 1, ,782 EBITDA – 2011 / 2012 (R$ MN) % % (175) EBITDA 2011 EBITDA 2012 Net Revenue Non- Managable Costs Managable Costs (PMSO) Provisions Regulatory Assets and Liabilities Adjusted EBITDA 2011 Adjusted EBITDA 2012 Other operational/ revenues

Net Income 4Q11 4Q12 EBITDAFinancial Result TaxesOthers ADJUESTED NET INCOME 4Q11 / 4Q12 (R$ MN) Regulatory Assets and Liabilities Adjusted Net Income 4Q11 Adjusted Net Income 4Q % (53) (68) (11) %

Net Income ADJUESTED NET INCOME 2011 / 2012 (R$ MN) % (85) (57) % EBITDAFinancial Result TaxesOthers Regulatory Assets and Liabilities Adjusted Net Income 2011 Adjusted Net Income 2012

Dividends

Indebtedness Average Term: 4,2 years AMORTIZATION SCHEDULE* (R$ MN) Nominal Cost Real Cost Dec/12Dec/11 3, ,273.1 NET DEBT *ConsideringHedge * Principal only COST OF DEBT US$/Euro 0.8% CDI/Selic 72.1% TJLP 25.1% % 8.21% 5.30% 9.84% 4.87% 11.08% 4.25% 11.03% 2012 Net Debt / EBITDA Others 2.0% , After 2017 The pre payment of R$ 375 million in October reduced the cost of debt and extended the amortization schedule

Investments CAPEX (R$ MN) CAPEX BREAKDOWN (R$ MN) Generation Projects 1.9 Quality Improvement Generation Maintenance 23.7 Others Develop. of Distribution System Losses Combat Investments in Electric Assets (Distribution) Commerc./ Energy Eficiency 26.1

Regulatory Framework  The Provisional Measure 579 was enacted on September 11, 2012 and thereafter converted into Law 12,783 providing for electric power concessions, reduction of sector charges and reasonable tariffs which although these have not directly affected Light, as its concessions will expire only in 2026, resulted in the following developments:  on January 24, 2013, Resolution issued by Aneel approved an average reduction of 19.63% in Light SESA’s tariffs. For residential consumers (low voltage), the reduction was 18.10%. The measure will have no impact on the company’s result or cash flow since it reflects an equal reduction in costs.  on the same date, the distribution of power plants energy quotas was ratified, which had their concession renewed:  (i) but lower to the distribution companies’ contracting needs, thus, causing an involuntary exposure, and only for Light it accounted for average 156 MW; and  (ii) made distribution companies to start sharing the hydrological risks, which before was only supported by generation companies  As of October 2012, an adverse hydrological situation was characterized in Brazil’s electricity sector, the basis of which is mainly hydric, enforcing the System National Operator to dispatch all the thermal power plants available in the system, thus significantly rising the costs of distribution companies by increasing fuel expenditures in availability agreements, increasing System Service Charges due to energy security and acquisitions on the spot market in order to answer that involuntary exposure.

 On March 8, 2013, the federal government issued the Decree 7,945 preventing the coverage of non-manageable costs related to thermal plant dispatch, involuntary exposure and hydrological risk not covered by the 2013 tariff, as follows:  Eletrobrás will transfer the resources of Energetic Development Accout (CDE) directly to the concessionaires on the same dates and to the same accounts as the respective monthly transfers of the Electricity Trading Chamber (CCEE) financial guarantees.  Aneel will publish the monthly dispatches with the amounts to be transferred by Eletrobrás via the CDE (energy development account).  System Service Charge (ESS) – The monthly transfer will be determined by the difference between the amounts settled in the CCEE and the tariff coverage defined in the last adjustment.  Involuntary Exposure associated with the quotas – The monthly CDE transfer will cover the difference between the difference settlement price (PLD) and the acquisition tariff of the repositioning amount recognized in Light’s last tariff adjustment.  Hydrological Risk - The net monthly amount settled in the CCEE will be transferred directly via the CDE.  The remaining energy purchase and ESS costs not covered by the decree, including fuel costs of availability contracts not included on tariffs, will continue going towards the formation of the regulatory assets and liabilities (CVA) to be determined in Light’s November/13 Tariff Revision.  The Public Hearing opened for regulating decree proposes a transfer rate until 3% of the balance of CVA, the rest will be payed "in cash" from CDE funds. Regulatory Framework

Important Notice This presentation may include declarations that represent forward-looking statements according to Brazilian regulations and international movable values. These declarations are based on certain assumptions and analyses made by the Company in accordance with its experience, the economic environment, market conditions and future events expected, many of which are out of the Company’s control. Important factors that can lead to significant differences between the real results and the future declarations of expectations on events or business-oriented results include the Company’s strategy, the Brazilian and international economic conditions, technology, financial strategy, developments of the public service industry, hydrological conditions, conditions of the financial market, uncertainty regarding the results of its future operations, plain, goals, expectations and intentions, among others. Because of these factors, the Company’s actual results may significantly differ from those indicated or implicit in the declarations of expectations on events or future results. The information and opinions herein do not have to be understood as recommendation to potential investors, and no investment decision must be based on the veracity, the updated or completeness of this information or opinions. None of the Company’s assessors or parts related to them or its representatives will have any responsibility for any losses that can elapse from the use or the contents of this presentation. This material includes declarations on future events submitted to risks and uncertainties, which are based on current expectations and projections on future events and trends that can affect the Company’s businesses. These declarations include projections of economic growth and demand and supply of energy, in addition to information on competitive position, regulatory environment, potential growth opportunities and other subjects. Various factors can adversely affect the estimates and assumptions on which these declarations are based on.

Contacts João Batista Zolini Carneiro CFO and IRO Gustavo Werneck IR Manager